Dual production well packer



Jan. 2, 1968 c. c. BROWN DUAL PRODUCTION WELL PACKER 7 Sheets-Sheet 1 Filed Jan. 24, 1966 Jan. 2, 1968 C. c. BROWN 3,361,208

DUAL PRODUCTION WELL PACKER ATTORNEYS. Y

Jan.2,1968 C. @BROWN 3,361,208

DUAL PRODUCTION WELL PACKER Filed Jan. 24, 196e 7 sheeis-Sheet s Jan. 2, 1968 C. C. BROWN DUAL PRODUCTION WELL PACKER Filed Jan. 24, 1966 l '7 Sheets-Sheet 4 c/cmo z'. BRow/v INVENTOR.

Jan. 2, 1968 C. C. BROWN 3,361,208

DUAL PRODUCTION WELL PACKER IL V ,BY 557W,

Jan. 2, 1968 C. c. BROWN 3,361,208

DUAL PRODUCTION WELL PACKER Jan. 2, 1968 c. c. BROWN DUAL PRODUCTION WELL PACKER 7 Sheets-Sheet 7 Filed Jan. 24, 1966 /CERO 6. @ROW/V l INVENTOR. mi

United States Patent Olice 3,361,208 Patented Jan. 2, 1968 3,361,268 DUAL PRDUCIION WELL PACKER Cicero C. Brown, 8490 Katy Road, Houston, Tex. 77h24 Filed Jan. 24, 1966, Ser. No. 522,449 14 Claims. (Cl. 16e-126)) The present invention relates to new and useful improvements in hydraulically actuated Well packers and relates particularly to dual-production well packers.

The invention is applicable -for use in anchoring Well devices, such as well packers and the like or well tubing, Within the bore of a well.

`In certain dual-production Well packers the forces exerted yupon the assembly have been carried by only one of the tubular supports. This unequal distribution of forces to the two tubular supports causes a bowing of the well packer assembly. Such bowing results in a cocking of the sealing assembly. When the packing element of the sealing assembly is cooked or displaced out of axial alignment with the well bore, the packing element `fails to hold well pressures.

This cocking of the packing element which results `from the variation of tensile stresses in the tubular supports occurs in dual-production well packers whenever one of the tubublar supports is slidable in one of the abutments of the support and the other tubular support is secured to both abutments. The stress dilferential may occur during setting of the well packer assembly or when the pressure loading held by the assembly is not uniformly distributed to the two tubular supports.

This cooking problem, while occurring in all dualproduction well packers which have one tubular support slidable in one abutment, is particularly pronounced in the type of dual-production well packers in which a single set of gripping elements is used to hold the unit against movement in both directions when the packer is exposed to high-pressure differentials although such structures have been -found to be satisfactory.

Dual-production well packers, which employ a single set of gripping elements for locking the packer against longitudinal movement in both directions, have come into ygeneral use for producing well fluids from two producing formations through independent tubing strings. The particular advantage of a packer having the single set of gripping elements locking in both directions is the elemination of radially movable hydraulically actuated holddown means. Although these units have been satisfactory under lower pressure conditions, it has been found that under higher pressure conditions the forces increase and tend to place an excessive tension on the single tubing string. Such excessive tension causes the aforementioned cooking problem. In some instances, the excessive tension may actually bend the tubing string, which is carrying the full load, at a point below the packer assembly.

It is, therefore, an important object of the present invention to provide a dual-production well packer assembly having two tubular supports, which assembly effectively distributes tension forces to both of the tubular supports and thereby eliminates the aforesaid diliiculty of cooking of the packing element.

Another important object of the present invention is to provide zan improved well packer adaptable for use in dual-production wells in which the tension forces to which the mandrels or tubular supports are subjected during setting and under load conditions are substantially equalized and distributed to both mandrels when set so that the cocking problem is eliminated.

A still Vfurther object 4of the present invention is to provide a well packer adaptable for use in dual-production wells which is hydraulically actuated into set position and locked in such set position until positively released by manipulation of one of the tubing strings and which will hold against longitudinal movement in both directions and eliminate the need for the hydraulic actuated holddown buttons.

Still another object is to provide a. hydraulically set well packer adaptable for use in dual-production wells wherein both of the tubing strings above the packer may be placed in tension after the packer has been actuated to set position.

The construction designed to carry out the invention will be hereinafter described, together with other features thereof.

The invention will be more readily understood from a reading of the following specilication and by reference to the accompanying drawings forming a part thereof, wherein an example or the invention is shown, and wherein:

FIGURE l is a sectional view illustrating the preferred for-n1 of well packer of the present invention with the various parts of the assembly being shown in the running postion while the assembly is being lowered within the well bore;

FIGURE 2 is a similar View illustrating the apparatus of FIGURE 1 with the packing element in =a set position;

FIGURE 3 is a view similar to views 1 and 2, showing the setting of the lower expander of the anchoring assembly;

FIGURE 4 is a similar view `showing the position of the parts of the well packer when it is completely set;

FIGURE 5 is another similar View showing the position of the parts after the well packer has been completely released;

FIGURE `6 is a vertical sectional view of the well packer taken along line 66 in FIGURE l and showing the gripping elements of the anchoring assembly and the locking means;

FIGURE 7 is an exterior view of the well packer with the parts positioned as shown in FIGURES 1 and 6 and illustrating the anchoring assembly and the releasable connections;

FIGURE 8 is a sectional View of the well packer taken along line 8-8 in FIGURE l showing the lateral relationship of the tubular supports and the locking pins;

FIGURE 9 is another sectional view of the well packer taken along line 9--9 in FIGURE 1 illustrating the anchoring assembly; and

FIGURE l0 is still another sectional view of the Well packer taken along line lll-llt in FIGURE 1 illustrating the force distributing means;

FIGURE ll is a sectional view illustrating a modified form of well packer with the various parts of the assembly being shown in the running position, while the assembly is being lowered within the well bore;

FIGURE l2 is a similar view illustrating the apparatus of FIGURE ll with the packing and anchoring assem- -blies in set position;

FIGURE 13 is another similar View showing the position of the parts after the well packer illustrated in FIG- URE 11 has been completely released;

FIGURE 14 isa sectional view of tlhe well packer illustrated in FIGURE 13 taken along line 14-14;

FIGURE l5 is a cross-sectional view of the well packer taken along line 15--15 in FIGURE l1;

FIGURE 16 is another cross-sectional view of the well packer taken along line 16-16 in FIGURE 14 to illustrate the hydraulically actuated hold-down buttons;

FIGURE 17 is an external elevation View of the anchoring assembly; and

FIGURE 18 is a cross-sectional view taken along line 18-18 in FIGURE 14 and illustrating the locking means which hold the setting means in set position.

The dualeproduction well packer of the present invention in its preferred form illustrated in FIGURES 1 to 10 has a Isingle anchoring assembly which, when hydraulically set, will be locked to hold the well .packer against movement both up and down. When set, forces on the well packer are directed tothe anchoring assembly to assure that it remains set. Such anchoring assembly, when installed in a dual-production well packer within a highpressure well, requires that tension developed in either one of the two tubular supports or mandrels be transmitted to the anchoring assembly to exert such force on the expanders tending to hold the slips or gripping elements in set or pipe-gripping engagement with the casing in which the assembly is set. In this well packer, the force distributing means assists in distributing the tension forces that develop in the mandrels to the anchoring assembly and thereby tends to equalize such forces lbetween both tubing strings.

Referring to the drawings, the well packer P is shown positioned within a well casing C and having a rst and a second tubular support or mandrel and 11) connected to the first and second tubing strings T-1 and T-2, respectively. The packing assembly B and the anchoring assembly A are mounted 4on the tubular supports 1t) and 11 with the setting means S positioned between such assemblies. The head 12, which is secured to tubular supports 10 and 11, forms the upper abutment for the well packer. The combination of a lower abutment and the release means R is provided by the threaded connection 13 between the rst tubular support 10 and the lower portion of the anchoring assembly A. The lower ends of the tubular supports 10 and 11 are surronded by the force distributing means F, as hereinafter more fully explained.

The upper abutment is formed by head 12. rIlhe head 12 is connected to tubular support 10 by the snap ring 14 which is held in position to prevent relative longitudinal movement of the tubular support 10 and the head 12 by the nut 15. The bearing ring 16 is positioned between the nut and the snap ring 14 to allow rotation of tubular support 10 within the head 12. A suitable seal 17, such as an O-rring, is provided between the exterior of tubular support 10 and the surface of the opening in head 12 through Which tubular support 10 extends. Tubular support 11 is threadedly secured within head 12. Head 12 is provided with a bore 18 in communication with the upper end of tubular support 11 to receive the tubing string T-2. The pins 19 which are secured in the bore 18 are adapted to engage J slots 20 in the lower end of tubing string T-2. The tubing string T-Z is provided with suitable lseals to engage against the surface of the bore 18 to prevent leakage of fluids flowing through tubbular support 11 and tubing string T-2. Tubular support 10 is directly connected to the tubing string T-l. Since head 12 is directly connected to both tubular supports 10 and 11, it functions as an upper abutment in the operation of the well packer P.

The packing assembly B is positioned immediately below the upper abutment and tubular supports 10 and 11 extend downwardly therethrough. The packing assembly B includes the elastic packing element 21 and the upper and lower followers 22 and 23, all of which are relatively rtree to move in sliding relationship to the tubular supports 10 and 11. The packing element 21 is the usual type which will expand radially outwardly against the Well casing C when `compressed longitudinally.

The setting means S is illustrated to be a hydraulically actuated means including the sleeve 24 and the piston 25, both of which surround the tubular supports 10 and 11, together with means to conduct the pressure fluid into the pressure chamber 26. The pressure chamber 26 is formed above the upper end of piston 25 and below the plate 27 which is secured to the sleeve 24. The means conducting the -pressure fluid into the pressure chamber 26 is the ports 26a extending through the mandrel 11.

A locking means is provided to coact with the setting means S to maintain the extended position of the setting means once it has been actuated. The locking means is illustrated in the FIGURES 6 and 8. The locking means includes the pins 28 and 29, each of which is threadedly engaged into the plate 27 and extends downwardly through the piston 25. The lower ends of the pins 28 and 29 are tapered to receive the locking slips 30 and 31 in the space surrounding the tapered portion of the pins and defined by the bore through the piston 25. Bolts 32 are secured into the lower ends of the pins 28 and 29 to support the rings 33 which `provides the upwardly facing shoulders for the springs 34. The springs 34, being supported by the shoulders of the rings 33, exert an upward force on the locking `slips 3G and 31 so that they will be urged upwardly on the tapered surface of the pins 2S and 29. Because of the taper of the pins, the force exerted by springs 34 will, therefore, urge the slips 36 and 31 into engagement with the surface of the bores through the 4piston 25. The teeth on the slips 30 and 31 are directed ydownwardly so that movement of the sleeve 24 upwardly and movement of the piston 25 downwardly are not resisted but the opposite movement of these parts is resisted by the locking means. Therefore, once the setting means S has been actuated by the movement of sleeve 24 upwardly and piston 25 downwardly, the locking means holds the setting means S in the set position. The shear pins 35 are provided to releasably secure the sleeve 24 to the piston 25.

The anchoring assembly A is positioned immediately below the setting means S on the tubular supports 1()` and 1l1 and includes the cage 36, the upper expander 37, lower expander 38 and the gripping elements 39. The expanders 37 and 38 are provided with pins 40 which are engaged in the vertical slots 411 in the cage 36 to prevent relative rotation of the expanders with respect to the cage. The cage is also connected by shear pins 42 and 43 to the upper and lower expanders 37 and 38, respectively. The windows 44 in the cage 36 allow the gripping elements to move inwardly and outwardly responsive to the engagement of the tapered surfaces of the expanders in the usual manner. Thus, a movement of the expanders toward each other causes the gripping elements to be moved outwardly into gripping engagement with the casing C, and a movement of the expanders away from each other allows the gripping elements to retract into cage 36.

'Ilhe release means R is the threaded connection 13 between the lower expander 38 and the tubular support 10. The sn-ap ring 45 is positioned in a groove in the tubular support 10 and within the upper portion of the lower expander 3'8 to engage the upper expander 37 on release. The interior surface of lower expander 38 above the threads 13 is spaced from the tubular support 10' so that it will not engage the snap ring 45 or the threads 13 on release.

The force distributing means F includes the plate 46 which surrounds the lower end of tubular supports 10 and 11. The nut 47 is provided with an upper outwardly extending iiange 48 which engages the upper surface of the plate 46 through the bearing ring 49. The nut 47 is in threaded engagement with the lower end of tubular support 10. The sub 50 is connected to the lower end of the tubular support 111 and provides the upwardly facing shoulder 51 which acts as an abutment means against which the force distributing plate 46 abuts when the nut 47 is completely tightened. With 4the plate 46 in this position, tubular support 11 is free to slide downwardly through the plate 46 but is not able to slide upwardly after the plate 46 engages the shoulder 51. 'Ilhe interior of the sub Str is reduced in area to provide a seat 52 for the setting ball 53. The sub 54 connects to the lower end of mandrel 1G and has an upwardly facing shoulder 55 which will support the plate 46 in the event the shoulder 51 moves down away from plate 46.

The `components of the well packer P are illustrated in FIGURE l in position for running the device into the well casing C. As shown, the packing element 21 is relaxed; the upper end of the sleeve 24 is in engagement with the packing follower 23 while the follower .22 is in engagement with the head 12; the lower end of the sleeve i i S 24 labuts the upper end of the cage 36; the lower end of the piston 2'5 abuts the upper end of the upper expander; all three shear pins 35, 42 and 43 are holding their respective connections; and, the force distributing plate 45 is secured by nut 47 against the shoulder 5l1. In this position, the well packer will be mounted on the tubing string T-1 and run into the well to the position at which it is to bet set.

In operation, after the well packer has been run into the well to the proper position, then the tubing string T-2 is lowered into the well and is landed within the bore 18 in the head 12. It should be noted that the upper surface of head 12 is tapered toward the bore 18 to assist in the location of the bore 18 while the tubing string T-2 is `being landed. When the tubing string T42 has been landed, it is rotated clockwise so that the pins 19 move up in the J slots 2t).

Thereafter, the device is ready for setting so the setting ball 53 or any other suitable plug is dropped through the tubing string T-2, and it lands on the seat 52 in the position shown in FIGURE 2 so that the tubing string T-2 and she tubular support 1-1 may be pressurized. The pressure fluid is conducted through the ports 26a into the pressure chamber 26. The pressure fluids exert an upward force on the plate 27 and sleeve 24 and a downward force on the piston 25. Since it is generally preferred that the packing assembly B be set rst, the shear pins 35 are made to `be weaker than the shear pins 42 and the shear pins 43. When the pins 35 shear, thesleeve 24 and the plate 27 move upwardly causing a setting of the packing element 21. The head 12 remains stationary to act as the upper abutment and to allow the packing assembly to be compressed Iby such upward movement of the plate 27 and the sleeve 24 to radially expand the packing element into the set position which is clearly illustrated in FIGURE 2.

As the pressure is maintained in the pressure chamber 26, it is exerted against the piston 215. The piston 25 moves downwardly as soon as the pressure in chamber 26 creates a force sufficient to shear the pins 43. This force is trans-mitted from tihe piston 2-5 through the upper expander 37, the shear pins 42 and the cage 36 to the pins 43. When the pins 43 shear, the piston 2.5 and the remainder of the anchoring assembly move downwardly on the lower expander 318 which is held by its threaded connection 13 to the mandrel 1G. This downward movement with respect to expander 38 moves the gripping elements 39 outwardly into pipe-gripping engagement with the wall of the casing C. Pins 43 are intentionally made stronger than pins 42 to assure that the lower expander' 38 is set with respect to the gripping elements 359 before the upper expander 37 is set. This partial set position of the anchoring assembly A is shown in FIGURE 3. The continued pressure wherein the chamber 26 ultimately shears the pins 42 and, thereafter, the downward `movement of piston 25 causes the upper expander 317 to be forced under the grip ping elements 39 4to also urge them into gripping po-sition with the casing C. The fully set position of the apparatus is illustrated in FIGURE 4. The design of the strength of the shear pins 35, 42 and 43 should be such that they can all `be sheared in the desired sequence without having to provide excessive setting pressure.

Once the device is fully set, the pressure wit-hin the tubing string T-2 and tubular support 11 is released and the locking means (slips 30 and 31 on pins 28 and 29) prevents a releasing movement of the sleeve 24 and the piston 25. In this position the well packer P is operative, and production may be commenced through the tubing strings T-l and T-2. Since the setting means S is held in its extended postion, the well packer remains set until positively released as hereinafter more fully explained.

The function of the force distributing means F is to provide a tension equalizing connection between the lower ends of the tubular supports and 11 without interfering with the setting or releasing ofthe well packer.

6 The setting of the well packer P does not in any way move the tubular supports 10 and 11 and, therefore, the force distributing plate 46 remains in engagement with the abutment means or shoulder 51. Once the well packer P has been set, both of the tubing strings may be placed in tension without releasing the packer. Tension in tubing string T-1 is transmitted directly through the tubular support 10 to the lower abutment or lower expander 38 which is urged upwardly and thereby applies a force through the inclined surfaces to urgedl the gripping elements 39, outwardly into firmer gripping engagement with the casing C to thereby assure the maintenance of the set position of the well packer P. Similarly, a tension in the tubing string T-2 will be transmitted through the tubular support 11 and the force distributing plate 46 to the tubular support 10 and thence to the lower expander 38 to also urge the gripping elements 39 in the outward direction. The teeth on the gripping elements 39 are designed to hold against forces in both directions, and will, therefore, assure the anchoring of the well packer against such tension forces. The forces developed by a pressure below the packer will create forces which are transmitted to the gripping elements 39- in the same manner as the tension forces in the tubing strings. When a pressure occurs above the well packer P, the forces will be exerted against packing element 21 downwardly and are transmitted directly to the upper expander 37 through the setting means S. The upper expander 37 will urge the gripping elements 39in an outward direction to maintain the anchored position of the well packer P. Thus, pressure differentials in both directions are utilized to assure the maintenance of the set position of the device.

The well packer P is normally released after the tubing string T-2 has been removed. The released means R, which is the threaded connection 13 between the tubular support 10 and the lower expander 38 which forms the lower abutment, is actuated by a manipulation of the tubing string T-1 at the surface of the well. Generally, it is preferred that the threaded connection 13 be lefthand threads so that the release rotation of the tubing string T-l will not have a tendency to unthread any of the joints of the tubing string. As the tubing string T-l is rotated for release, the lower expander 38 moves downwardly to be withdrawn from under the gripping elements 39. Thereafter, the tubing string T-l is raised and the snap ring 45 will engage the lower edge of the upper expander 37 and cause it to be pulled from under the gripping elements 39. In actual practice, if a dovetail type of construction of the gripping elements 39 is used, the lower expander is moved downwardly only a slight distance, that distance allowed by the tolerances in the tongue and slot connection between the slips and the lower expander. Then the upper expander is retracted from under the gripping elements to cause t-he gripping elements to retract and the lower expander at the same time to move downwardly allowing complete release of the anchoring assembly A. As the tubular support 10 is raised, it will lift head 12 to thereby remove the upper abutment and allow the plastic packing element 21 to relax into unset position. This unset or released position of the anchoring assembly A and the packing assembly B is illustrated in FIGURE 5. In this position, the well packer may be withdrawn from the well..

It should be noted from FIGURE 5 'that the relative positions of the sleeve 24 and the piston 25 are not changed by the release of the Well packer P. They are securely held in their actuated or extended position by the engagement of the locking pins 28 and 29 with the plate 27 and the engagement of the locking slips 30 and 31 with the piston 25. It should also be noted that suitable seals are provided surrounding the locking pins 28 and 29, between the piston 25 and the sleeve 24 and between the plate 27 and the sleeve 24 to prevent leakage of the pressure fluids from the` pressure chamber 26 during t-he setting of the well packer P.

Also, the release of the well packer is accomplished by the rotation of the tubing string T-l and the tubular support 10, which release is in no way hindered by the connection between the lower ends of tubular supports 1t)- and 11 by the force distributing means F.

The modified form of dual-production well packer of the present invention, illustrated in FIGURES 11-18, has the usual anchoring assembly with gripping elements designed to hold the well packer assem-bly against movement in a downward direction within the well bore and also hy-draulically actuated gripping means which are actuated by pressure from below to hold the well packer assembly from movement in an upward direction. This Well packer assembly requires that one of the tubular supports on which the remainder of the assembly is mounted be slidable with respect to one of the abutments, and, therefore, is subject to the aforementioned cocking problem. This cooking problem is eliminated by providing the force distributing means to assist in distributing tension forces developed in the tubular supports or mandrels and thereby tends to equalize such forces and eliminates the source of the cooking problem.

Referring to the drawings, the well packer P-1 is shown positioned within a well casing and having a first and a second tubular support or mandrel 110 and 111 connected to the rst and second tubing strings T-3 and T-4, respectively. The packing assembly B-1 and the anchoring assembly A-l are mounted on the tubular supports 110 and 111 with the setting means S-1 positioned below such assemblies. The head 112, which is secured to tubular supports 110 and 111, forms the upper abutment for the well packer assembly. The combination of a lower abutment and a release means R-1 is provided by the threaded connection 113 between the first tubular support 110 and the lower portion of the setting means S-l. The lower ends of the tubular supports 110 and 111 are surrounded by the force distributing means F-1, as hereinafter more fully explained.

Since both tubular supports are connected to head 112, it forms the upper abutment of the Well packer assembly. The tubular support 110 is connected to the head 112 by the snap ring 114 which is held in position by the nut 115. This connection prevents relative longitudinal movement of the tubular support 110 in relation to the head 112 while allowing the tubular support 110 to be rotated Within the head 112. A suitable seal 117, such as an O-ring, is provided between the exterior of tubular support 110 and the surface of the opening in head 112 through which the support 110 extends. Tubular support 111 is threadedly secured within the head 112. The head 112 is provided with a bore 118 in communication with the upper end of tubular support 111 to receive the second tubing string T-4. The pins 119 which are secured in the bore 118 are adapted to engage J-slots 120 in the lower end of tubing string T-4. The tubing string T-3 is provided with suitable seals to engage against the surface of the bore 118 to prevent leakage of fluids flowing through tubular support 111 and tubing string T-4. Tubular support 110 is directly connected to the first tubing string T-S. Since the head is directly connected to both tubular supports 110 and 111, it functions as the upper abutment in the operation of the Well packer assembly P-l.

The packing assembly B-l is positioned immediately below the upper abutment formed by the head 112 and the tubular supports 110 and 111 extend downwardly therethrough. The packing assembly includes the elastic packing elements 121, the upper and lower followers 122 and 123 and the central follower 124, all of which are relatively free to move in sliding relationship to the tubular supports 110 and 111. The packing elements 121 and the followers 122 and 123 are the usual type which will expand radially outward against the well casing C-1 when compressed longitudinally.

The anchoring assembly A-1 is positioned immediately below the packing assembly B-1 in surrounding relation to the tubular supports and 111. The anchoring assembly includes the expander 125, the -gripping elements 126 shown in FGURE 14, and the base plate 127 to which the gripping elements are connected by the usual T connection 128 as best seen in FIGURE 17. Relative movement between the expanders and the gripping elements 126 will cause the radial movement of the gripping elements 126.

The base plate 127 provides the upper movable portion for the setting means S-1. The sleeve 129 is threadedly secured to the base plate 127 and extends downwardly around lower abutment 130 and is secured thereto by shear pin 131. The lower abutment 130 is threadedly connected to the tubular support 110 by the threaded connection 113 to provide the release means R-1. The tubular support 111 is provided with ports 132 communicating with the pressure chamber 133 between the lower surface of the base plate 127 and the upper surface of the lower abutment 130 in an area defined by the sleeve 129. The sub 134, which connects to the lower end of the tubular support 111, is provided with a seat 135 to receive the setting ball 136 (shown in FIGURE l2) which is utilized to actuate the setting means S-l.

A locking means is provided to coact with the setting means S-1 to maintain the extended or set position of the setting means once it has been actuated. The locking means is most clearly illustrated in FIGURE 14 and includes the pins 137, 13S, each of which is threadedly engaged into the base plate 127 and extends downwardly into the lower abutment 130. The lower abutment 130 is recessed at its lower end to receive the sealing rings 139 and 140 and the locking slips 141 and 142 surrounding the lower ends of the pins 137 and 138. Additionally, the inserts 143 and 144 are threadedly secured in the lower abutment 13) and provide internal tapered surfaces against which the gripping elements 141 and 142 will coact to force their gripping teeth into engagement with the outer surface of the pins 137 and 138. Thus, when pressure exists in pressure chamber 133, this pressure will be exerted against the sealing rings 139 and 140 to force the locking slips 141 and 142 against tapered surfaces on the inserts 143 and 144 to cause engagement of the teeth of the slips 141 and 142 with the exterior of the pins 137 and 138. As can be seen from FIGURE 14, the teeth on the locking slips 141 and 142 are directed upwardly to thereby allow an upward or setting movement of the pins 137 and 13S and to prevent a downward or release movement of such pins in relation to the lower abutment 130 even when the pressure in chamber 133 has been exhausted. Suitable seals are provided around the tubular supports 110 and 111 in the setting assembly and around the interior of sleeve 129 both above and below the pressure chamber 133.

The force distributing means F is positioned in surrounding relationship to both of the tubular supports 110 and 111 at a position spaced below the lower abutment 130. The plate 145 of the force distributing means F surrounds the lower ends of the tubular supports. The nut 146 is provided with an upwardly, outwardly extending flange 147 which retains the plate 145 by engagement with the bearing ring 148. The nut 146 is in threaded engagement with the lower end of the tubular support 110. The sub 134, which is connected to the lower end of tubular support 111, has an upwardly facing shoulder 149 which acts as an abutment means against which the force distributing plate 145 abuts when the nut 146 is tightened. With the plate 145 held against the shoulder 149, the tubular support 111 is free to slide downwardly in relation to the plate 145, but any upward force thereon will be transmitted by the shoulder 149 to the plate 145. The sub 15@ is connected to the lower end of the tubular support 110 and has upwardly facing shoulder 151 which will engage the plate 145 whenever the sub 134 moves downwardly a short distance below the plate 145,

The snap rings 152 and 153 are provided in the exterior of tubular supports 110 and 111 at a position to engage the interior of the expander 125 when the packing and anchoring assemblies are in the running position. The expander 125 is provided with internal clearance with respect to snap rings 152 and 153 to allow setting motion, upwardly with respect to the tubular supports, without interference from the snap rings 152 and 153.

The hydraulically actuated gripping means are included within the head 112. These gripping means include the usual hold-down buttons 154 which are exposed to the uid pressures below the packing assembly B1. The communication to the hold-down buttons 154 extends through the expander 125, the packing assembly B-l and into the head 112 as the passageways 155 and 156, each leading to one of the hold-down buttons 154. In this manner, the pressure beiow the packing assembly will be conducted through the passageways 155 and 156 to expand the hold down buttons 154 outwardly into engagement with the casing to prevent upward movement of the well packing assembly whenever pressure below the packing assembly exceeds the pressure above the packing assembly. The hold-down buttons are designed to have teeth directed in an `upward direction to resist such upward movement. These hold-down buttons are necessary since the gripping elements 126, having downwardly directed teeth, will not hold against forces tending to move the well packer assembly upwardly.

The components of the well packer P-1 are illustrated in FIGURE l1 in position for running the device into the well casing C-1. As shown, the packing assembly B-l is relaxed; the expander 125 is engaged by the snap rings 152 and 163; the shear pin 131 is in position retaining the setting means S-l in the unset position; and, the force distributing plate 145 is secured by the nut 146 against the shoulder 149. In this position the well packer will be mounted on the first tubingtstring T3 and run into the well to a level at which it is to be set.

After the packer assembly has been run into the Well to the proper position, the tubing string T-4 is lowered and landed Within the bore 118 in the head 112. It should be noted that the upper surface of the head 112 is tapered toward the bore 118 to assist in landing the tubing string T-4 therein. When the tubing string T-4 is landed in the bore 118, it is rotated clockwise so that the pins 119 move up in the I-slots 120.

Thereafter, the device is ready for setting and the setting ball 136 is dropped through the tubing string T-4. When the setting ball 136 is positioned on the seat 135, the tubing string T-4 and tubular support 11 are pressurized. The pressure iluid within the tubular support 111 is con ducted through the ports 132 into the pressure chamber 133. The fluid pressure exerts an upward force on base plate 127 and a downward force on lower abutment 130. Since lower abutment 130 is connected to the tubular support 110, the base plate 127 and sleeve 129 move upward whenever pressure provides suliicient force to shear the shear pins 131.

The upward movement of the base plate 127 reduces the distance available between the upper abutment 112 and the lower abutment 113 and causes the packing assembly B-1 and the anchoring assembly A-l to be moved to set position. With the pressure being maintained within the chamber 133, the base 127 continues its upward movement. This upward movement moves the gripping elements 126 and expander 125 upwardly to cause the packing elements 121 to be compressed and thereby expand radially outward into sealing engagement with the wall of the casing C-1 as shown in FIGURE 12. Additionally, this upward movement causes the gripping elements 126 to move upwardly `with respect to the expander 125. Because of the tapered surfaces between the expander 125 and the gripping elements 126, the gripping elements are forced outwardly into engagement with the wall of casing C-1. The downward deflection of the teeth of the gripping elements 126 allows a continued upward movement of the elements even after they have engaged the wall of the casing C-1 to assure that the packing assembly B-1 is completely set.

When the packing assembly B-l and the anchoring assembly A-1 are completely set, the pressure in the tubing string T-4 and, consequently, in chamber 133 may be reduced without releasing these assemblies. The loc-king means of the pins 137 and 133 cooperating with the locking slips 141 and 142 retains the setting means S-1 in its extended position to prevent unsetting or release upon pressure reduction. `In this position, the well packer T-1 is operative and production may be commenced through the tubing strings T-3 and T-4. Since the setting means S-l is held in its extended position by the locking means, the well packer remains set until positively released as hereinafter more fully explained.

As in the preferred form previously described, the function of the force distributing means F-l is to provide a tension equalizing connection between the lower ends of the tubular supports and 111 which does not intertere with the setting and releasing of the well packer. The setting of the well packer P-1 does not move either or" the tubular supports and, therefore, the force distributing plate 145 remains in engagement with the shoulder 149; Tension in the tubing string T-3 is transmitted directly through the tubular support 110 through the lower abutment and the locked setting means S-1 to the gripping elements 126 thereby urging the gripping elements outwardly into tighter engagement with the well casing C-1. Similarly, a tension developing in the tubing string T-4 is transmitted through the tubular support 111 and the force distributing plate to the tubular support 110 to also urge the gripping elements 126 into tighter engagement with the casing. Since the gripping elements 126 are not designed to hold against an upward movement, this transmission of forces by the plate 145 will not prevent upward movement ot the well packer assembly but will equalize the tension forces between the two tubular supports.

Such tension forces may be created by the pressures held by the well packer assembly or also by the setting action of the unit. These forces arise during setting because the lower abutment 130 is secured only to the tubular support 110, and, thus, the total pressure lin the pressure chamber 133 will be exerted on the tubular support 11i). This force will be transmitted through the threaded connection 113 and the force distributing means F-1 to the tubular support 111 to thereby prevent cooking of the unit.

The well packer P-1 is normally released after the tubing string T-4 has been removed. The release means R-1, which is the threaded connection 113 between the tubular support 110 and the lower abutment 130, is actuated by a manipulation of the tubing string T-3 at the surface of the well. Generally, it is preferred that threaded connection 113 be left-hand threads so that the release rotation of the tubing string T-3 does not have a tendency to unthread any of the joints of the tubing string. As the tubing string T-3 is rotated for release, the tubular support 110 moves upwardly. This upward movement, because of the engagement of the snap ring 114, lifts head 112 upwardly allowing the packing assembly B-1 to relax. Further movement of the tubular support 110 causes the snap rings 152 and 153 to engage the interior of the expander 125 and lift the expander out from under the gripping elements 126. This upward movement of the expanders 125 will cause the gripping elements 126 to retract because of the `usual dove-tail connection between the expander 125 and the gripping elements 126 which is best seen in FIGURES 14 and 15. At this point, the release of the well packer assembly is complete and the components will be positioned as shown in FIGURE 13. Thereafter, the well packer may be removed from the well bore -by raising the tubing string T-3.

This release of the well packer from set'position does l l not change the position of the components of the setting means S-1 as they remain locked in their extended or set position even after complete release.

From the foregoing description it can be seen that the present invention provides a dual-production well packer which can be set within a well casing and which will hold against longitudinal movement in both directions without the use of supplemental hydraulic hold-down buttons. The packer also allows both of the tubing strings to be maintained in tension once the well packer has been set. Further, the well packer is provided with a force distributing Ine-ans which will equalize the tension forces which may develop in the respective tubular supports and thereby prevent leakage or failure which could result from having the two tubular supports under widely diiferent tension strains or from one tubular support carrying all of the tension load.

The foregoing disclosure and description of the inven tion are illustrative and explanatory thereof and various changes in the size, shape and materials, as well as in the details of the illustrated construction, may be made within the scope of the appended claims without departing from the spirit of the invention.

What is claimed is:

1. A well packer adapted to be lowered and set within a dual-production well pipe, comprising a first tubular support,

a second tubular support,

an upper abutment mounted on said tubular supports,

a lower abutment mounted on said tubular supports and spaced longitudinally from said upper abutment,

a packing assembly mounted on said tubular supports between said abutments,

an anchoring assembly including gripping elements mounted on said tubular supports between said abutments, pressure-responsive setting means mounted on said tubular supports and coacting with the packing assembly and the anchoring assembly to move said `assemblies into set position when actuated by uid pressure, the setting of said anchoring assembly moving said gripping elements of said anchoring assembly into pipe-gripping position with said well pipe, and

means connecting the irst and second tubular supports and forming a force distributing means which transmits tension forces from one tubular support to the other.

2. A well packer according to claim 1, wherein said gripping elements are adapted to hold against longitudinal movement in both directions when moved into pipe-gripping position with said well pipe.

3. A well packer according to claim 1, wherein said force distributing means includes a torce distributing plate surrounding both of said tubular supports, one of said supports being free to slide through said ring in one direction only and the other of said tubular supports being secured to said plate.

4. A well packer according to claim 3, including abutment means on the one of said tubular supports which is free to slide through said plate for engagement with said plate when said one of said tubular supports is subjected to tension forces.

5. A well packer according to claim 4, including an `adjustable connection between said plate and said tubular support to which said plate is secured, actuation of said adjustable connection .presetting said plate in engagement with said abutment means.

6. A well packer according to claim 5, wherein said first tubular support is secured to both of said upper and lower abutments and said second tubular support is secured only to said upper abutment,

said abutment means is positioned on said second tubular support at its lower end,

said lirst distributing plate is secured to said rst tubular support and engaging said abutment means on said second tubular support to transmit tension forces in said second tubular support to said first mandrel.

7. A well packer according to claim 1, wherein said presure-responsive setting means includes a piston,

a sleeve surrounding said piston,

an end plate on said sleeve dening a pressure chamber at one end of said piston,

said sleeve and said piston both being movable responsive to fluid pressure with respect to said upper and lower abutments to coact with said packing assembly and said anchoring assembly to move said assemblies into set position.

8. A well packer according to claim 7, including locking means associated with said pressure-responsive setting means to allow setting movement and prevent return movement of said setting means.

9. A well packer according to claim 7, including a locking pin secured to one of said sleeve and said piston and extending into a bore in the other of said sleeve and said piston,

the free end of said locking pin being tapered to a smaller diameter,

locking slips engaging the tapered portion of said pin and having teeth gripping the surface of said bore, and

spring means urging said slips onto said taper to force said locking slips into engagement with said bore,

the teeth on said slips being inclined to allow setting movement of said sleeve and said piston and to prevent an unsetting return movement of said sleeve and said piston.

10. A well packer adapted to be lowered and set witha dual-production well pipe, including an elastic packing element,

an anchoring assembling including pipe-gripping elements,

said pipe-gripping elemetns when in pipe-gripping position within a well pipe holding the well packer against both up and down movement,

setting means associated with said packing element and said anchoring assembly for setting said plastic element and said gripping elements into engagement with the wall of the well pipe,

release means for releasing said anchoring assembling and said packing element from set position,

a rst tubular support,

a second tubular support,

said tubular supports extending through said packing element, said anchoring assembly and said setting means whereby said supports are anchored and sealed in position in the well pipe by said element and said anchoring assembly when in set position, and

means connecting the rst and second tubular supports and forming force distributing means which transmits tension forces from one tubular support to the other.

l1. A well packer adapted to be lowered and set within a dual-production well pipe, including a rst tubular support,

a second tubular support,

an upper abutment mounted on said tubular supports,

a lower abutment mounted on said tubular supports and spaced longitudinally from said upper abutment,

a packing assembly mounted on said tubular supports between said abutments,

an anchoring assembly mounted on said tubular supports between said abutments,

presure-responsive setting means mounted on said tubular supports and coacting with the packing assembly and the `anchoring assembiy to move said assemblies into set position when actuated by fluid pressure, and

locking means coacting with said setting means to lock said setting means in set position,

the release of said other abutment being accomplished by manipulation of the tubular support to which it is secured to eect release of said packing assembly from set position and to also effect release of said gripping elements of said anchoring assembly from pipe-gripping position with said well pipe.

12. A well packer according to claim 11, wherein the setting of said anchoring assembly moves the gripping elements of said anchoring assembly into pipegripping position with said well pipe to hold against longitudinal movement in both directions.

13. A well packer according to claim 11, wherein 14 said locking means includes a spring; urging said locking means into locking position. 14. A well packer according to claim 11, wherein said locking means includes a piston urging said locking means into locking position responsive to the setting pressure of said pressure-responsive setting means.

References Cited UNITED STATES PATENTS 2,999,543 9/1961 Myers 166-189 X 3,115,185 12/1963 Brown 166-119 3,166,127 1/1965 Brown et al 16S-189 X 3,167,127 1/1965 Sizer 166-189 X 15 JAMES A. LEPPINK, Primary Examiner. 

1. A WELL PACKER ADAPTED TO BE LOWERED AND SET WITHIN A DUAL-PRODUCTION WELL PIPE, COMPRISING A FIRST TUBULAR SUPPORT, A SECOND TUBULAR SUPPORT, AN UPPER ABUTMENT MOUNTED ON SAID TUBULAR SUPPORTS, A LOWER ABUTMENT MOUNTED ON SAID TUBULAR SUPPORTS AND SPACED LONGITUDINALLY FROM SAID UPPER ABUTMENT, A PACKING ASSEMBLY MOUNTED ON SAID TUBULAR SUPPORTS BETWEEN SAID ABUTMENTS, AN ANCHORING ASSEMBLY INCLUDING GRIPPING ELEMENTS MOUNTED ON SAID TUBULAR SUPPORTS BETWEEN SAID ABUTMENTS, PRESSURE-RESPONSIVE SETTING MEANS MOUNTED ON SAID TUBULAR SUPPORTS AND COACTING WITH THE PACKING ASSEMBLY AND THE ANCHORING ASSEMBLY TO MOVE SAID ASSEMBLIES INTO SET POSITION WHEN ACTUATED BY FLUID PRESSURE, THE SETTING OF SAID ANCHORING ASSEMBLY MOVING SAID GRIPPING ELEMENTS OF SAID ANCHORING ASSEMBLY INTO PIPE-GRIPPING POSITION WITH SAID WELL PIPE, AND MEANS CONNECTING THE FIRST AND SECOND TUBULAR SUPPORTS AND FORMING A FORCE DISTRIBUTING MEANS WHICH TRANSMITS TENSION FORCE FROM ONE TUBULAR SUPPORT TO THE OTHER. 